Your SlideShare is downloading. ×
A Day in the Life of the Grid
Upcoming SlideShare
Loading in...5
×

Thanks for flagging this SlideShare!

Oops! An error has occurred.

×
Saving this for later? Get the SlideShare app to save on your phone or tablet. Read anywhere, anytime – even offline.
Text the download link to your phone
Standard text messaging rates apply

A Day in the Life of the Grid

77
views

Published on

This snapshot of the hour-by-hour operation of a large regional transmission organization on a hot summer day illustrates the benefits of greater regional oversight of the transmission system and …

This snapshot of the hour-by-hour operation of a large regional transmission organization on a hot summer day illustrates the benefits of greater regional oversight of the transmission system and points the way to even greater benefits, as end‐use customers gain the ability to interact with the regional wholesale market.

Published in: Technology, Business

0 Comments
0 Likes
Statistics
Notes
  • Be the first to comment

  • Be the first to like this

No Downloads
Views
Total Views
77
On Slideshare
0
From Embeds
0
Number of Embeds
1
Actions
Shares
0
Downloads
3
Comments
0
Likes
0
Embeds 0
No embeds

Report content
Flagged as inappropriate Flag as inappropriate
Flag as inappropriate

Select your reason for flagging this presentation as inappropriate.

Cancel
No notes for slide

Transcript

  • 1. 1   A Day in the Life of the Grid: July 21, 2011 This  snapshot  of  the  hour-­‐by-­‐hour  operation  of  a  large  regional  transmission   organization  on  a  hot  summer  day  illustrates  the  benefits  of  greater   regional  oversight  of  the  transmission  system  and  points  the  way  to  even   greater  benefits,  as  end-­‐use  customers  gain  the  ability  to  interact  with  the   regional  wholesale  market.   by  Paul  Feldman   ISO the Midwest Independent Transmission System Operator1 is an independent regional transmission organization that encompasses all or part of 11 states. MISO manages a large portion of the bulk electric system in the central and upper Midwest through an organized market. This approach provides buyers and sellers the real, instantaneous price of 1  MISO r -‐time wholesale electric energy markets, directing and controlling over 131,000 MW of generating resources and approximately 50,000 miles of transmission lines. Consumer loads in the MISO region have been as high as 104,000 MW during peak summer days, and MISO settles more than $23 billion in gross market charges annually. wholesale electricity over a region, which has a huge intra-‐day and geographical variance. Exposing these prices, along with technology and tariff advances over the past several years, gives rise to even more opportunities for economically attractive transactions at M Paul  Feldman,   independent  Board  of  Director,  extends  his    who   were  instrumental  in  preparing  the   information  presented  here.     to  the  National  Association   of  Utility  Regulatory  Utility  Commissioners  in   February.  The  video  presentation  is  posted  on   the  MISO  website  linked  here  and  below.  
  • 2. 2   the retail level, through improved coordination between the wholesale and retail markets. Improvements in communicating accurate retail price signals to end-‐use consumers, coupled with providing them access directly or indirectly to the wholesale markets would allow their consumption decisions to benefit themselves and general market outcomes. To the extent these opportunities are wisely pursued, the bulk electric system can be made less expensive and more reliable for all. This may soon be possible, but there is still a lot to be done. This presentation was developed to show how the wholesale market works and why it is important to retail pricing decisions and, ultimately, the end-‐ customer. While this is based on events within the MISO footprint, the hour-‐by-‐ hour observations made here would apply to virtually all RTOs. MISO uses price maps to show energy prices across its regional footprint throughout each day. This link to a video from the MISO website depicts the series of price maps from Wednesday July 21, 2011, which shows the changing price of wholesale electricity across the 24 hours of the day. The time of day is registered in the upper right corner. The price maps are a direct reflection of the least cost deployment of resources throughout the region while respecting the reliability criterion to protect the system from any single generator or transmission outage. he prices depicted are actual Locational Marginal Prices, or LMPs for short. The prices are represented by colors, with the highest prices being orange to red in the 10 to 20 cents per kilowatt-‐ hour range, and the lowest prices being green to blue in the 3 cents to zero cents per kWh range. While the video shows Megawatt-‐hour prices, w divide these by 1,000 and use kWh prices to better make the connection to retail reality. These are the actual prices for wholesale electricity prices an economist would like to see motivate energy decisions. As you watch the video or follow developments in the text below, think about how these widely varying wholesale prices compare with the average, time-‐constant retail price that most people and businesses actually pay and the disparity between the two. Remember that the disparity is quite expensive at peak load periods, contributing to a greatly underutilized, but very expensive asset: the generation and transmission facilities which comprise the bulk electric system. Also, think about the end-‐customer assets distributed generation or T Consider  how  widely-­‐varying  wholesale   prices  compare  with  the  average,   time-­‐constant  retail  price  that   most  customers     and  the  disparity  between  the  two.  
  • 3. 3   reduced customer demand that could be called upon that customers might choose to make available in return for a substantial saving. Finally, think about how these savings could be used by consumers and businesses alike to invest in our economy, while strengthening the bulk power system at the same time. Other things to note: The faint gray dotted lines shown throughout the region are existing 345 kV transmission lines. The heavy dark lines shown on the map are the 16 elements of a $5.8B Multi-‐Value Project (MVP) portfolio of proposed transmission lines. This portfolio is specifically designed to reduce congestion in the MISO footprint and enable least cost generation to reach load throughout the footprint. In December, 2011, the MISO Board approved implementation of this portfolio after careful and considerable review of a very conservative business case that includes a Benefit to Cost Ratio of more than 2 to 1. A 2 to 1 Benefit to Cost ratio is an extraordinary value in any business. For now many low cost wind generation resources are largely trapped in the western part of the MISO regional footprint, as you will see through this peak day and virtually all future days until more transmission is built. No Wednesday July 21, 2011, and take a closer look at each of these 24 hours and . . . Midnight: It is midnight moving into July 21, 2011. The previous day had been swelteringly hot, and we are starting a new day expected to be just as hot. peak for the MISO region was almost 104 GW about 15% of the electricity used in the entire US. similar. Figure 1 is a price map for midnight July 21, the beginning of our day. A transmission constraint has caused the high prices observed at this unusual time, a graphic illustration of -‐value transmission projects are designed to prevent. Instructions have already been sent to every one of over 1,300 generation and participating load-‐side resources in the footprint letting them know what conditions are expected each hour of Figure  1    
  • 4. 4   the day. These instructions will be monitored throughout the day and modified as conditions dictate, but every five minutes a reminder or new instruction packet is released so everyone is up to date on next steps. Wholesale price volatility is a very real and daily phenomenon caused by widely ranging fuel prices, very limited storage ability, weather conditions, transmission line constraints, and other factors. You are looking at the state-‐of-‐the-‐art in terms of price setting delivering prices that result in lowest cost system deployment and high reliability. The system planning and resource adequacy efforts have targeted only one end-‐user outage every 4,000 days. not all. These prices are transparent to everyone, and therefore used to inform future bilateral contracts governing the value of these contacts by shedding a bright light on true costs. Where organized markets do not exist price discovery is more of an art-‐form. Throughout the ensuing description, I will weave in a few vignettes, which mix fact and fiction a bit to make a point of possible interest. However, despite any fictional elements they are all entirely possible and realistic today. 1:00 AM: We are one hour into implementing the grid management plan for the day. As shown in Figure 2, prices are below 3 cents/kWh across the region except on the southern Illinois-‐ Indiana border, where a transmission constraint has limited the flow of low-‐ cost power into the area and 10 cent/kWh generators have been brought on line to serve the load. Just 130 miles north of the 10 cent energy price, zero variable cost wind resources are trapped and cannot get out due to lack of transmission line capacity, driving prices to zero. Operators in the control room are constantly looking at the weather forecast and system conditions. Software runs quietly in the background collecting data from 250,000 points every 4 seconds across the grid on cyber-‐secure channels. The same systems check every potential grid failure point every 89 seconds and calculate protective reactions for every one of them. B Figure  2  
  • 5. 5   Meanwhile, prices are determined and posted every 5 minutes for energy and multiple ancillary service products for each of 1,976 locations. You are looking at just energy prices and not all the separately-‐priced ancillary services products, although there is a very high price correlation between all these products at any moment in time. 2:00 AM: By 2:00 AM, with more people in bed, temperatures and load across the region has dropped off further. Wind generation output is at 3.5 GW, leaving 6.5 GW of name-‐plate, zero incremental cost wind capacity unproductive for lack of wind. ransmission constraints are virtually nonexistent, as load is down and the system is greatly underutilized. Shop-‐Mart, a large multi-‐state retailer, monitors the weather daily and predicts that prices today at the wholesale level will be even higher than yesterday due to higher forecasted temperatures in the region. The corporate energy manager gave orders to offer all of their demand response capability into the MISO market wherever states allow such action. Many states pictured here and elsewhere are sorting through options related to allowing end-‐customers to access wholesale markets directly, through aggregators, through energy companies, or combinations thereof. Shop-‐Mart is a sophisticated energy user with many locations and capability to control HVAC, refrigeration, and lighting that would allow them to save millions of dollars each year if they could consistently participate in organized market demand response and ancillary service program tariffs. Such access would have the additional benefit of lessening the need for future generation, increasing reliability, dampening wholesale prices in the near term, and freeing capital for investment. 3:00 AM: Figure 3 shows that prices are near zero in the western portion of footprint. Wind farms producing with a fuel cost of zero are willing to be paid anything above minus 2.9 cents per kWh as they receive a Production Tax Credit of 3 cents/kWh for energy they actually produce. A data center in White Fish Bay, Wisconsin, carries out orders left earlier in the day to fully charge all batteries at the $0 price they expect at this hour. The data center exists on an industrial campus configured as a microgrid and has access to the wholesale market as an industrial customer. Every electric car expected to be built in the next 15 years could charge at this hour and not strain the bulk power system. Even the most aggressive retail Time of Use tariffs that have been adopted have minimum prices far in excess of the actual variable price of electricity at this moment. This leaves lots of room for states to consider stimulating the electric vehicle market. T
  • 6. 6                 4:00 AM: MISO control room operators continue to monitor the software outputs and keep an eye on the 10 by 70 foot data screen that dominates the control room in Carmel, Indiana. Systems in the St. Paul, Minnesota backup control center 581 miles away are updated on a real-‐time basis and operators there are ready to take over on a flash-‐cut basis in the event of a failure at the main control center. There is little change from the prior hour, as system load settles in at its minimum for the day 67 GW. The equivalent of more than 23 nuclear plants will be fired up in the next few hours to meet the peak later in the day. Prices in the west plummet to zero and below, as load drops off and the wind is generating at 3 GW. On the early morning of the peak day and the most expensive day for the year the average real wholesale price across the entire footprint between midnight and 4:00 AM is 2.3 cents per kWh. On this same day in this same footprint, actual price of gasoline is $3.82. Working through the math, if you wanted to buy an incremental mile of fuel for your car right now, gasoline is over 1800% more expensive than electricity. 5:00 AM: People in Michigan are starting to get up and turn things on. Prices rise as more expensive, although still cheap, generation is brought on-‐ line in anticipation of the daily ramp up. Winds in Lafayette, Indiana, are non-‐ existent and the football-‐field-‐long turbine blades stand idle in what is usually a very windy area. Figure  3  
  • 7. 7                 6:00 AM: Demand is increasing faster in the eastern portion of the footprint than in the west, as the sun continues to clear the eastern horizon. A price-‐ map of each ancillary service product would show very similar price separation and variability across the region. ning but a price disparity between Iowa and Michigan is already obvious in Figure 4. Incremental energy in Iowa is nearly free, while in Michigan energy is already up to 7.5 cents per kWh, reflecting transmission constraints that prohibit less expensive energy from flowing into the state. Michigan would clearly benefit from additional transmission into the state. 7:00 AM: Winds have started to pick up in Lafayette, Indiana and wind generation is ramping up inside this traditionally transmission-‐constrained area. Low cost generation is trapped in the area because there is not enough transmission to move it out to where it is needed. This results in all generators in the area that are subject to market prices receiving a near zero price. The two dark lines out of the area show proposed transmission lines that will ultimately move the low cost energy to a wider market, resulting in a lower cost to the overall footprint and giving the wind generator a better price for its product ind creates some unique challenges to a balancing authority. Despite its near zero variable costs, in a small balancing reliability issues and additional costs as other resources are needed to manage capacity. MISO transitioned in 2009 from 23 balancing authorities to a single balancing authority, allowing these challenges to be better managed at the lowest cost. The geographic diversity of MISO also moderates the overall variability of the wind. The scale of the footprint also provides more options in siting of wind, allowing states lacking wind resources greater access to higher wind capacity resources. MISO is similar in size and geographical diversity and was previously similar in W Figure  4  
  • 8. 8                 terms of its proliferation of Balancing Authorities to the Western Interconnection, minus California. 8:00 AM: As Figure 5 shows, trapped wind in west-‐central Indiana is pushing prices to zero and less, while nearly adjacent areas are at $100 per MWh more than twice the average system price. Grid software has properly determined that raising the price on the high-‐price-‐ side of the transmission constraint and electrically pushing back on the constraint will enable the lowest total cost for the region at this moment. Traders caught short in the red area are not happy campers. Dealing with constraints is also an area where end-‐customer resources can prove to be of value in lowering cost and maintaining reliability. Software overlays from either aggregating energy companies or independent aggregators can configure end-‐customer resources to provide energy and ancillary service-‐ equivalent functionality to the grid operator, who remains legally agnostic between the possibilities. Over the long term, traditional generation assets and end-‐customer resources that can be configured to provide grid services should each contribute according to their marginal cost structures and fine-‐ grained functionality. MISO launched an ancillary services market in 2009, which resulted in a large increase in the value MISO provides, as measured annually in its ongoing Value Proposition Study. A good example of this is the provision of frequency regulating reserves which manage the instantaneous changes in load that continuously occur on the system. Prior to 2009, each balancing authority managed its own regulation, typically with reserves held on its newest coal units, which tended to have the best control systems. In total, over 1,100 MW of low-‐cost coal generation was held back for regulation. Consolidation into a single balancing authority and providing frequency regulation through a central market allowed the regulation requirement to be reduced to less than 400 MW, and Figure  5  
  • 9. 9                 also allowed the requirement to be met with less efficient units, freeing up the most efficient units for energy production the equivalent of four low cost coal units. The result is an annual savings of $176-‐$195 million. 9:00 AM: Interpreted appropriately, Locational Marginal Prices are markers pointing to opportunities to lower cost and improve reliability. Constraints, which are indicated by price differences in the region, should be examined for ways to improve the cost efficiency of the system. Detailed examination should examine several options for each constraint, looking for the most cost-‐ effective way to deal with the constraint, options include: additional generation, additional transmission, and load-‐side resource participation opportunities. In high load areas that presently experience constraints, blocking access to low cost generation, demand response options can be a very efficient option. Currently in the MISO region, most demand side resources are not offered for use to the wholesale market except in emergency situations creating economic inefficiencies. Load-‐ side solutions are also inherently clean, fast and do not suffer from NIMBY issues. Several companies have now adopted the Green Button a customer-‐ friendly means to view actual system real-‐time costs, and a necessary step in the direction of end-‐user cost control. Of course not every nail needs one of these hammers. It may be appropriate to accept inefficiency in cases where the cost of a constraint is small enough, or the constraint may occur so infrequently, that the best economic decision is to accept the inefficiency cost than any of the other options. In most of the western portion of the Eastern Interconnect, and the eastern portion of the Western Interconnect, customers only have the option of wholesale market access through their local energy company, based on retail tariffs. Other areas of the country allow aggregators to approach customers with a wide variety of increasingly innovative offers related to participation in wholesale markets. State regulators have to sort out the right approach for customers. oving to the MISO control room, at 9:34 AM operators declare a Maximum Generation Warning as load is tracking ahead of forecast and forced outages are exceeding expectations. Models suggested the warning four minutes ago as the appropriate next step. At 9:35, frequency dips to its low for the day at 59.964. Generation is falling a bit behind the morning ramp up. Among large customers, Shop-‐Mart energy manager sends an e-‐mail to its control center asking if everyone is ready to shed 50 MW of load between 1:00 and 2:00 this afternoon as per schedules with the Grid Operator. The email was unnecessary; it was covered on software-‐driven autopilot since M
  • 10. 10                 orders were issued earlier in the day. 10:00 AM: Things continue to heat up, and the morning ramp the rate of load increase is formidable. To further complicate the ramp-‐up, wind is falling off a cliff and wind-‐driven blades are slowing across the region. Current forecasts are for peak-‐wind to be a full 3 GW less than the peak wind from yesterday; about 3 nuclear plants worth of generation missing in action. Two other challenges are surfacing. The weather pattern across the footprint shown is unusually homogeneous, taking away the innate ability to take advantage of weather diversity in a large footprint. That will cause more resources to be committed later this afternoon. And, finally imports from some energy to take advantage of higher prices in the eastern part of the MISO footprint are drying up, as prices rise substantially in the Mid-‐Atlantic States. PJM is facing its peak day for the year. Grid management software continues to operate in the background of the Data Center, which is redundantly connected to the Control Room. The software has been subtly altered over the past couple of years from simply bringing on enough generation to meet load changes to align with a new approach to grid management. The objective function of the software is to run the grid as efficiently as possible while maintaining reliability, using any resources available. revolutionary implications. An efficient grid is a low cost and reliable grid. To run an efficient grid, system operators need to direct the flow of energy, and to support that flow with a suite of ancillary services e.g., frequency regulation, spinning reserves, non-‐ spinning reserves, etc. The grid operator is legally agnostic as to who provides these services traditional generators or equivalent actions on the customer side of the equation. Both traditional generators and customer-‐side assets are offering their capabilities into the market, and the software is selecting whatever the most efficient resources are resources that provide the lowest cost delivered energy Figure  6  
  • 11. 11                 in a reliable fashion. Every day more customer assets are being offered into the market and replacing traditional generation assets that are higher cost. Even at this mid-‐ morning hour, Figure 6 shows and increasing cost trend, a normal very early in the trend toward customer participation but the trend is there pushed by technology advances and Smart Grid-‐ caused customer education and awakening. At this moment, thousands of entrepreneurs are dreaming up ways to enable customers to participate in the process and leverage the still-‐evolving Smart Grid system. The beneficiaries will be the end-‐customers and just in time given price pressure driven by aging generation plant retirements and higher plant replacement costs not to mention sorely needed distribution upgrades. 11:00 AM: Very high prices in excess of 10 cents/kWh -‐start to surface in central Illinois (Figure 7), as the Chicago area draws energy from the southwest and transmission lines are nearing their capacity. While generators in the PJM region had been selling into the MISO market earlier in the day, MISO is now exporting over 500 MW to PJM a trend that will grow and continue through the heat of the day. The pattern of very high/very low prices in a tight, adjacent geographical setting efforts to achieve low cost across the footprint in the face of those constraints. Think of the transmission grid as a system of pipes with flowing water. A constraint hampers the flow of cheap water. More of the cheap water can get into the network if someone will apply pressure to the pipe discharging toward the cheap water and distribute it to other pipes. Grid operators do that by turning on more expensive generation at the other end of the constrained line resulting in increased prices on one end of the constraint. This causes less stress on the constrained line and the lowest cost possible in the footprint, given the constraints and resources available. Figure  7  
  • 12. 12                 mathematically far more complicated than that, of course. 12:00 noon: Prices have soared above 10 cents/kWh in the east more than a 400% increase over the early morning hours. The wholesale markets are a true reflection of the actual cost of electricity at each of 1,975 locations every 5 minutes. At this moment the real cost of energy in Illinois, Indiana, Michigan, and Ohio is well in excess of the retail price every customer is actually charged. The disparity between the real wholesale price and the retail price that actually drives customer decision-‐ making leads to massive inefficiencies, waste, and severe under-‐utilization of a $1 trillion asset. Retail Time-‐Of-‐Use pricing that at least roughly aligns with the wholesale reality could help a lot a tricky business as well. At 12:45 PM, a plant in Indiana trips off line and the loss of over 400 MW of power ripples across the Interconnect at 60% of the speed of light, and frequency in the entire interconnect dips to 59.967 hertz -‐ the second lowest for the day. The dip is responding to the loss of generation. Through a combination of software-‐driven actions, frequency recovers in less than 5 minutes. Synchrophasors across the eastern half of the continent log the event to within one-‐millionth of a second the time it takes electricity to travel two football fields. (Synchrophasors measure voltage and current at diverse locations on a power grid and can output accurately time-‐stamped voltage and current. In the larger world of -‐h minor occurrence. The grid is always protected against any single event and the only impact of the instantaneous loss of over 400 MW is a slight price increase as the supply curve shifts left to recognize more expensive generation coming on-‐line. (Figure 8.) The grid is then immediately reconfigured to protect against the next potential event. Figure  8  
  • 13. 13                 1:00 PM (13:00hrs): Average temperatures in the region are nearing 100 degrees, and wind has dropped off to less than 1 GW. Effectively, only 1,800 of the 30,000 wind blades in the region are producing at capacity. Grid operators dispatch the next batch of least-‐cost generation, which is almost always the most expensive generation on the system. Average prices in the east are 300% higher than prices in the west. Some rain and cloud cover flattens the load growth at the 100.5 GW level, while the system peaks at 3.5 GW less than yesterday. Figure 9 shows the condition of the network at 1 PM. At 1:00 PM exactly, a signal goes out to 717 IP addresses from Shop-‐Mart s control center freeing a 50 MW chunk of the demand response capability. Actions taken within 31 seconds include light dimming, a 3.7 degree rise in refrigeration units, and a 2.1 degree temperature rise in selected stores. No store employee or customer notices as the program automatically grinds on for the next hour, reducing system peak, saving over 50 MW of high-‐ cost, on-‐peak energy, and providing substantial savings to Shop-‐Mart. Among the consequences of Shop-‐ action are these: $10,000 flows to Shop-‐ bottom line; the bulk electric system is slightly more reliable ; a slightly lower price for all customers in the interconnect; saving of the cost to generate 4.3 MW that would have been lost in transmission and distribution lines and spread to customers; a savings of the cost to carry 7.5MW of reserve margin that would have been spread across all customers, a reduction of 70 tons of CO2 emissions for which Shop-‐Mart is not paid, slightly reduced earnings for a traditional generator, slightly less earnings for distribution companies serving Shop-‐Mart locations, and slightly less future need for new Figure  9  
  • 14. 14                 transmission and generation construction. There are many pieces here for utilities, customers, and regulators to consider. In other action, the Alcoa smelter in Newburgh on the southern Indiana border has been providing frequency regulation service to the grid since early morning, reacting to a 4 second signal just as it does every other day. Now Alcoa drops its demand by 80 MW from 480MW to take advantage of a $200 per MWh price. The economic goal simply switched from making beer cans to making negawatts, while as much of the smelter capacity as possible was reduced for an hour. For a typical aluminum smelter, electric power costs account for 30% to 40% of the total cost of producing primary aluminum. In the continental United States, Alcoa currently owns and/or operates ten aluminum smelters and many associated fabricating facilities with a combined average load of over 2,600 MW. 2:00 PM (14:00hrs): The end-‐customer events in the last hour highlight the beginning of a trend toward more end-‐customer participation. Huge decreases in communication costs and advances in digital technologies are enabling new load side (customer-‐side-‐of-‐the-‐meter) assets the flexibility to control their power usage and their power costs. Demand response resources have been called upon east of MISO, lowering prices for the Interconnect, but further demand response by MISO member customers are not needed. Reserve margins are adequate for the day, with the Shop-‐Mart and Alcoa actions noted above. Looking at the colors and changing patterns shown in Figure 10, it is impossible to infer anything about the effect of state boundaries; the states are all essentially in the same electrical boat when it comes to operation of the bulk electric system. ing to look at the map and consider incremental transmission construction and who wins and who loses if it is built. States with lower cost resources have the benefit of economic stimulus Figure  10  
  • 15. 15                 through increased exports to higher cost areas. States gaining access to lower cost resources have the economic stimulus of lower end-‐customer bills, freeing up cash for local expenditures and investment. and publicly available analysis shows that every sub-‐ region is a winner for the proposed transmission builds. 3:00 PM (15:00hrs): High prices in the east and central portions of the footprint ease due to a combination of a flattening demand and an increase in power imported from external suppliers that occurred during the prior hour. A weather front moving across the Midwest is lowering humidity levels and causing increased cloud cover in some areas, ending the escalating temperatures. This relieves most of the congestion on the transmission system for now. However, at 3:55 PM, another plant in southern Indiana, with a capacity of almost 500 MW, trips off-‐line. The grid software, which runs a co-‐optimized real-‐time energy and operating reserve market, has procured and deployed enough reserve capacity to protect the system. Reserves represent another ancillary services product for which end-‐ customer resources can be readily configured via software and offered into the market for payment. Again, the event is easily handled by the software which reconfigures the grid and gives everyone new marching orders within a few minutes. 4:00 PM (16:00hrs): Load for the MISO region continues to peak at 100.5 MW, down about 3 GW change in weather for parts of the region. Current real time prices in the Milwaukee area are some of the lowest across the footprint (Figure 11), as temperatures peaked there hours earlier as a result of changing weather conditions and transmission constraints at the Wisconsin -‐ Illinois border. Automatic five-‐minute dispatch instructions and price signals are incenting generators in the Milwaukee area to reduce their output to mitigate congestion, thus trapping low cost Figure  11  
  • 16. 16                 power that could otherwise reduce costs across the footprint. The short black line connecting Wisconsin and Illinois represents a proposed six-‐mile segment of 345 KV transmission that would alleviate this congestion, allowing customers to the south and east access to this low cost generation in Wisconsin. ust to the east, PJM sets a new all-‐ time peak at 160 GW at the same moment wind in PJM reaches its lowest point for the day at 300 MW down 1.3 GW from earlier in the day. The west-‐to-‐east price pattern is indicative of the normal relative price arrangement teeing up the need for west to east transmission to deliver lower cost resources where prices are higher. 5:00 PM (17:00hrs): After several very hot days, customers are demanding more energy for air conditioning. Traditional generation assets are stressed and many have had to de-‐rate and reduce output due to temperature. Grid operators are immediately and automatically software-‐notified of reduced capability. Wholesale prices are between 10 cents and 20 cents per kWh across the region. Peak hours drive the need for new construction in generation, transmission, and distribution. At this moment, the 61 million people in this picture are all making electricity decisions based on average and at this moment far too low retail electricity prices. Retail prices across the footprint signal end users that electricity is no more valuable now than it was at 4:00 AM despite a 20 cent/kWh-‐plus cost difference. The implications of low retail prices artificially incenting excessive customer demand, notably on-‐peak, include: unneeded construction, higher bills, unnecessary pollution, and increased energy dependence. Opportunities for customer demand response and supply from distributed generation still have a contribution to make, however. Back at the data center in White Fish Bay, with batteries at full charge and three days of fuel on hand for back-‐ up generators, data center management decides to kick in all five of its 2 MW generators and sell power back into the grid. They have access to the $200 MWh price, but their incremental cost to generate is only $20 per MWh, thus they are able to make $1,800 this hour lowering their total monthly energy bill by 3% for this one hour action alone. There is an amazing 170 GW of this type of customer side generation across the US, with less than 1% of it being maximized for the cu through access to wholesale markets. Alcoa returned to full beer can production 3 hours ago but now prices are at 45 cents/kWh and they happily shed 80 MW of load again for the next hour before returning to a standard production schedule. Organized markets and the ability to profit from customer response to power prices help make the economics of this facility work. The United States, once the leading aluminum producer, J
  • 17. 17   has been surpassed by China, Russia, and Canada. The long term viability of these types of facilities within the US is contingent upon cost reduction and cost competitiveness. 6:00 PM (18:00hrs): Things are starting to cool off in the west and prices are less than half what they were just an hour ago. 7:00 PM (19:00hrs): Even as temperatures cool slightly, MISO operators are still faced with nine binding constraints in the region three more than last hour. Each constraint means that lower cost powe On a day like today, operators are never relieved of this effort. During the cooler morning hours they only had three to five constraints to manage, but during the day as many as thirteen were actively being managed. 8:00 PM (20:00hrs): The heat index along the Lake Michigan shoreline in eastern Wisconsin has fallen materially in the last hour. Demand there continues to fall and prices continue to signal for less generation. Additional constraints, effectively a lack of transmission capacity to transport cheap energy out of this region, trap low cost generation in the area. 9:00 PM (21:00hrs): As street lights come on and households increase power consumption, the steady decline in demand over the last couple of hours is momentarily slowed. The continued removal of generating capacity from the system combines with this brief period of flattening demand to cause the need for some short-‐term, high-‐cost generation relief. Constraints continue to trap generation in Wisconsin. Although prices are higher for this short period, it is still the least cost deployment for the region considering what had to be done in previous hours, and the needs ahead. Economics for Alcoa have again flipped from making beer cans, so the company again sheds 80 MW of load in exchange for the 34 cents/kWh price. Alcoa is a great example of a large end-‐customer actually changing its operation to improve profitability and contribute to a more efficient grid at the same time. At the other extreme of size, a residential electric hot water heater or an aggregate arrangement of them that can be controlled is pretty much the same as a smelter and can provide the same services to the grid. Aggregated across many residential customers of such an asset can function as a low cost, highly reliable asset for use in frequency regulation, reserves, or An  aggregation  of  residential  electric  hot   water  heaters  that  can  be  controlled     has  pretty  much  the  same  value     to  the  system  as  a  smelter  and  can     provide  the  same  services  to  the  grid.    
  • 18. 18   energy source or sink. Many cooperatives and municipals are at the leading edge of using residential hot water management programs to cut peaks and reduce their system cost. Even if we undertake massive reforms to better manage electricity, there will always be locational price separation and inter-‐minute price volatility. And there will always be opportunities for end-‐customers to participate in a meaningful way. 10:00 PM (22:00hrs): Load resumes its decrease across the footprint as people go to bed and temperatures drop. Prices also begin to decrease (Figure 12) as the system has more generation than needed to meet demand. The only place prices have not dropped is in southwest Indiana, where the two large coal units had tripped off-‐ line earlier in the day as previously reported. The transmission capacity in the area is not enough to support low cost imports into the area resulting in high priced generation to meet the local load. 11:00 PM (23:00hrs): Demand begins to decrease more rapidly as temperatures drop and more people go to bed. Congestion continues in southwest Indiana. The Shop-‐Mart energy manager went to bed an hour ago, but wakes up suddenly from a dream that she had saved her company $10,000 earlier in the day. As it turns out, all the enabling tariffs are not in place yet and she still has work to do on the regulatory front. 12:00 PM (24:00hrs): The system becomes unconstrained as load continues to drop. MISO operators begin the cycle again driven, as always by the goal of providing a low-‐cost, reliable grid to the region, shedding light on the real cost of electricity, and assisting the region to plan for future system improvements. Published with permission from MISO. Figure  12  Figure  12

×